E.ON Webinar Lokala Flexibilitetsmarknader 2026-2027 (2026)

Title: Mer om årets lokala flexibilitetsmarknader 2026/2027 (recorded webinar, linked from eon.se/flex). Presenters: Adam Christensson (marknadsansvarig, southern markets) and Elham Kalhori (marknadsansvarig, central Sweden). Audience: potential flexibility service providers (FSPs).

Summary

E.ON’s public season-overview webinar ahead of the 2026/2027 local flexibility market season. The most operationally detailed public account of E.ON’s SWITCH local flexibility markets to date: it reports the just-finished 25/26 season outcomes, lists the 12 winter markets plus the Halland summer pilot, and — crucially — gives concrete figures for the three products, the remuneration model, gate-closure times, the 75% delivery threshold, and the supplier-onboarding process. Confirms the thin-market problem from the operator’s own side and frames participation as an under-exploited business opportunity.

Season 25/26 outcomes (operator-reported, public)

• Cold winter, record flexibility demand. Both the forecast flex need (which orders are based on) and the realised need were high. Södra Skåne saw a realised need of ~12,000 MWh over the winter.
• Realised demand was far above the pre-season estimate.
• The increase was driven mainly by flex needs arising over many more hours than in earlier seasons. On 10 of 11 markets, flexibility was demanded for at least double the hours estimated pre-season; several markets ~500–600 hours, and two markets 1,000–1,500 hours.
• More frequent orders. Bids from active FSPs covered only a marginal share of the need: after dispatching all available bids, the majority of need remained unmet on 10 of 11 markets, and 3 of 11 markets had no active suppliers at all.
• Activation occurred on 7 of 11 markets. Average activation price ~5,800 SEK/MWh (pay-as-bid, FSP-set). E.ON frames these high prices — relative to ancillary-services (stödtjänst) prices — as reflecting limited competition and substantial unmet need, i.e. an under-exploited business opportunity for new suppliers.

Why flexibility (E.ON’s framing)

Electrification raises grid loads and changes the system profile (decentralised, intermittent solar/wind; more prosumers), creating complex flows; building new grid is slow and expensive. Market flexibility is one competitive tool (alongside villkorade anslutningsavtal, technical solutions, and effekttariffer later) to connect customers faster and use the grid more efficiently. Three stated reasons: climate (E.ON’s grid spans ~4× the earth’s circumference — less build-out needed), cost-efficiency (the electrification bill ultimately lands on the ordinary nätkund), and faster connection / local growth. For an FSP, acquiring controllable effekt is framed as cost-control in its own right; once acquired, the same capability earns a second revenue stream on the LFM (paid both to stand ready and to activate).

2026/2027 markets

12 winter markets (Alvesta is the new addition, up from 11) plus the Halland summer pilot. Per-market needs were restated and broadly match the published figures (see E.ON Energidistribution › Published flexibility needs by market area); the substantive update is Nordöstra Skåne now active to ≥2030 (10 MW, 50–100 h) and the new Alvesta market (5 MW, 50–100 h, active ≥2031).

Alvesta also covers the Alvesta Energi / Alvesta Elnät consumption area — customers of Alvesta Elnät can deliver to E.ON’s market because the binding bottleneck sits upstream of Alvesta Elnät in the system.

Halland summer pilot 2026

A continuation of the 2025 pilot, running 1 June – 30 September 2026. It is the inverse of the winter markets: a production-side down-regulation (nedreglering) market — reduce production / increase consumption — driven by large intermittent-renewable connection plus summer heat reducing line capacity. Located around and north-east of Falkenberg. New this year: an intraday-trading pilot (trading closer to the operating hour) to test whether better forecast accuracy eases participation. Minimum bid 0.1 MW; participation requirements as for the winter markets.

Products & remuneration

• Market period (winter): November–March; needs typically a couple of hours in the morning and afternoon.
• Trading: via SWITCH (manual web interface or API); free for suppliers to participate.
• Participation requirements: a flexible resource that can reduce consumption or increase production; minimum bid 0.1 MW (aggregation allowed for smaller resources); 1-hour endurance; a sub-meter (undermätare) or billing meter (debiteringsmätare) to evidence delivery.
• Baseline methods: own reference plan (historical data), zero-reference, or MBMA / meter-before-after (the hour before and the hour after the activation become the reference values, from the connection-point meter).

Three products:

• Availability remuneration: fixed; activation is self-set, pay-as-bid (Säsong & TO have both; DO is pay-as-bid activation only).
• Standard availability price: 3,500 SEK/MW/h on all markets except Södra Skåne (up to 5,800 SEK/MW/h, with an impact factor applied).
• Säsongstillgänglighet remuneration: up to 236,000 SEK/qualified MW (daily model) or 354,000 SEK/qualified MW (intraday model), depending on endurance; covers December–February, weekdays 07:00–11:00 and 16:00–20:00.
• Endurance factor (uthållighetsfaktor): 100% = 4 hours; lower endurance reduces remuneration linearly down to 62% at 1 hour.
• Impact factor (påverkansfaktor) — Södra Skåne: qualified resources get a factor 0–1 at qualification that scales the fixed availability remuneration. Worked example: a 1 MW battery in Malmö with factor 0.6 and a contracted max of 5,800 SEK/MW/h receives an effective 3,500 SEK/MW/h (i.e. the standard rate).
• Gate-closure / dispatch: TO — bidding closes D-2 10:00, activation dispatch D-1 10:30. DO day-ahead — bidding closes D-1 19:00. DO intraday — bidding closes H-3, dispatch H-2. Säsongstillgänglighet — bidding closes two weeks before the period; activation dispatch D-1 10:30.
• Delivery / settlement: below 75% delivery → no remuneration (neither activation nor availability); at 75% → full availability + 75% of activation, then linear to 100%. E.ON currently applies no penalty fees for non-delivery — only the remuneration for the dispatched flexibility is withheld. Most suppliers reportedly have good delivery quality.

Becoming a supplier (process)

1. Map your own resources (heat pumps, EV charging, ventilation, backup power, etc.).
2. Register interest at eon.se/flex → E.ON makes contact and opens a dialogue covering metering (billing meter vs sub-metering), reference-plan type, impact factor, and market area.
3. Supplier qualification — a simple procurement form (company, contact, market area); reportedly ~2 minutes.
4. Onboarding in SWITCH — a SWITCH account, platform training, integration build (development → production environment, with the supplier’s own optional tests), and resource registration. After that, a fully qualified supplier.

Key claims and observations

1. Thin market confirmed from the operator side: 25/26 saw record demand but 3 of 11 markets had zero active suppliers, the majority of need was unmet on 10 of 11, and activation reached only 7 of 11 — the clearest operator-stated quantification of the supply deficit, corroborating the SWITCH CSV-export analysis.
2. ~5,800 SEK/MWh average activation price (pay-as-bid) — high, attributed to limited competition.
3. First granular public remuneration figures: 3,500 (5,800 Södra Skåne) SEK/MW/h availability; séasonal 236,000 / 354,000 SEK/MW caps; endurance factor 100%→62%; the Södra Skåne impact-factor worked example.
4. Three named products (Säsongstillgänglighet, Tillgänglighetsordrar, Direktordrar) with distinct notice/payment structures; TO’s ≥D-2 notice is explicitly framed as enabling coordination with ancillary-services markets (e.g. mFRR).
5. 75% delivery threshold with linear scaling above it, and no penalty fees beyond withheld remuneration.
6. Halland summer pilot is a production-side nedreglering market and is piloting intraday trading in 2026 — a forecasting-improvement experiment (closer to gate closure).
7. MBMA defined as the hour-before and hour-after connection-point readings.
8. Alvesta market includes the Alvesta Elnät consumption area (bottleneck upstream).

Relevance to wiki topics